US9476639B2 - Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column - Google Patents

Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column Download PDF

Info

Publication number
US9476639B2
US9476639B2 US12/869,007 US86900710A US9476639B2 US 9476639 B2 US9476639 B2 US 9476639B2 US 86900710 A US86900710 A US 86900710A US 9476639 B2 US9476639 B2 US 9476639B2
Authority
US
United States
Prior art keywords
stream
column
expanded
vapor
components
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active, expires
Application number
US12/869,007
Other languages
English (en)
Other versions
US20110067442A1 (en
Inventor
Tony L. Martinez
John D. Wilkinson
Joe T. Lynch
Hank M. Hudson
Kyle T. Cuellar
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Honeywell UOP LLC
Original Assignee
Ortloff Engineers Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Ortloff Engineers Ltd filed Critical Ortloff Engineers Ltd
Priority to US12/869,007 priority Critical patent/US9476639B2/en
Priority to PE2012000349A priority patent/PE20121422A1/es
Priority to KR1020127009963A priority patent/KR101619568B1/ko
Priority to EP10817650A priority patent/EP2480845A1/en
Priority to EA201200524A priority patent/EA021947B1/ru
Priority to BR112012006279A priority patent/BR112012006279A2/pt
Priority to JP2012529779A priority patent/JP5793144B2/ja
Priority to PCT/US2010/046953 priority patent/WO2011034709A1/en
Priority to EA201200521A priority patent/EA028835B1/ru
Priority to BR112012006219A priority patent/BR112012006219A2/pt
Priority to NZ599331A priority patent/NZ599331A/en
Priority to JP2012529781A priority patent/JP5793145B2/ja
Priority to PE2012000352A priority patent/PE20121420A1/es
Priority to NZ599333A priority patent/NZ599333A/en
Priority to SG2012014452A priority patent/SG178933A1/en
Priority to CA2772972A priority patent/CA2772972C/en
Priority to EP10817651A priority patent/EP2480846A1/en
Priority to CN201080041904.9A priority patent/CN102498360B/zh
Priority to CN201080041508.6A priority patent/CN102498359B/zh
Priority to EP10825365.9A priority patent/EP2480847A4/en
Priority to NZ599335A priority patent/NZ599335A/en
Priority to CA2773211A priority patent/CA2773211C/en
Priority to PCT/US2010/046967 priority patent/WO2011049672A1/en
Priority to EA201200520A priority patent/EA024075B1/ru
Priority to MX2012002969A priority patent/MX2012002969A/es
Priority to PCT/US2010/046966 priority patent/WO2011034710A1/en
Priority to PE2012000351A priority patent/PE20121421A1/es
Priority to SG2012014445A priority patent/SG178603A1/en
Priority to JP2012529780A priority patent/JP5850838B2/ja
Priority to AU2010308519A priority patent/AU2010308519B2/en
Priority to KR1020127009964A priority patent/KR20120072373A/ko
Priority to MX2012002970A priority patent/MX351303B/es
Priority to AU2010295870A priority patent/AU2010295870A1/en
Priority to BR112012006277A priority patent/BR112012006277A2/pt
Priority to SG2012015392A priority patent/SG178989A1/en
Priority to CA2773157A priority patent/CA2773157C/en
Priority to KR1020127009836A priority patent/KR20120069729A/ko
Priority to CN201080041905.3A priority patent/CN102575898B/zh
Priority to MX2012002971A priority patent/MX348674B/es
Priority to AU2010295869A priority patent/AU2010295869B2/en
Priority to TW099131475A priority patent/TW201111725A/zh
Priority to TW099131477A priority patent/TW201127471A/zh
Priority to TW099131479A priority patent/TWI477595B/zh
Priority to SA110310707A priority patent/SA110310707B1/ar
Priority to SA110310705A priority patent/SA110310705B1/ar
Priority to SA110310706A priority patent/SA110310706B1/ar
Priority to ARP100103435 priority patent/AR078403A1/es
Priority to ARP100103434A priority patent/AR078402A1/es
Priority to ARP100103433A priority patent/AR078401A1/es
Assigned to ORTLOFF ENGINEERS, LTD. reassignment ORTLOFF ENGINEERS, LTD. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: CUELLAR, KYLE L., MARTINEZ, TONY L., HUDSON, HANK M., LYNCH, JOE T., WILKINSON, JOHN D.
Publication of US20110067442A1 publication Critical patent/US20110067442A1/en
Priority to EG2012030439A priority patent/EG26970A/xx
Priority to EG2012030437A priority patent/EG27017A/xx
Priority to CL2012000687A priority patent/CL2012000687A1/es
Priority to ZA2012/02634A priority patent/ZA201202634B/en
Priority to ZA2012/02633A priority patent/ZA201202633B/en
Priority to ZA2012/02696A priority patent/ZA201202696B/en
Priority to CO12064992A priority patent/CO6531456A2/es
Priority to CO12064988A priority patent/CO6531455A2/es
Priority to CO12065754A priority patent/CO6531461A2/es
Priority to US15/259,891 priority patent/US20160377341A1/en
Application granted granted Critical
Publication of US9476639B2 publication Critical patent/US9476639B2/en
Assigned to UOP LLC reassignment UOP LLC ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: ORTLOFF ENGINEERS, LTD.
Active legal-status Critical Current
Adjusted expiration legal-status Critical

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0204—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the feed stream
    • F25J3/0209—Natural gas or substitute natural gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0233—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 1 carbon atom or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J3/00—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification
    • F25J3/02—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
    • F25J3/0228—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream
    • F25J3/0238—Processes or apparatus for separating the constituents of gaseous or liquefied gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream characterised by the separated product stream separation of CnHm with 2 carbon atoms or more
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J5/00—Arrangements of cold exchangers or cold accumulators in separation or liquefaction plants
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/02—Processes or apparatus using separation by rectification in a single pressure main column system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/30—Processes or apparatus using separation by rectification using a side column in a single pressure column system
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/74—Refluxing the column with at least a part of the partially condensed overhead gas
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/76—Refluxing the column with condensed overhead gas being cycled in a quasi-closed loop refrigeration cycle
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/78—Refluxing the column with a liquid stream originating from an upstream or downstream fractionator column
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/90—Details relating to column internals, e.g. structured packing, gas or liquid distribution
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/90—Details relating to column internals, e.g. structured packing, gas or liquid distribution
    • F25J2200/92—Details relating to the feed point
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2200/00—Processes or apparatus using separation by rectification
    • F25J2200/90—Details relating to column internals, e.g. structured packing, gas or liquid distribution
    • F25J2200/94—Details relating to the withdrawal point
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2205/00—Processes or apparatus using other separation and/or other processing means
    • F25J2205/02—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum
    • F25J2205/04—Processes or apparatus using other separation and/or other processing means using simple phase separation in a vessel or drum in the feed line, i.e. upstream of the fractionation step
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/06—Splitting of the feed stream, e.g. for treating or cooling in different ways
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2210/00—Processes characterised by the type or other details of the feed stream
    • F25J2210/60—Natural gas or synthetic natural gas [SNG]
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2215/00—Processes characterised by the type or other details of the product stream
    • F25J2215/60—Methane
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2230/00—Processes or apparatus involving steps for increasing the pressure of gaseous process streams
    • F25J2230/08—Cold compressor, i.e. suction of the gas at cryogenic temperature and generally without afterstage-cooler
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2235/00—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams
    • F25J2235/60—Processes or apparatus involving steps for increasing the pressure or for conveying of liquid process streams the fluid being (a mixture of) hydrocarbons
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2240/00—Processes or apparatus involving steps for expanding of process streams
    • F25J2240/02—Expansion of a process fluid in a work-extracting turbine (i.e. isentropic expansion), e.g. of the feed stream
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2240/00—Processes or apparatus involving steps for expanding of process streams
    • F25J2240/40—Expansion without extracting work, i.e. isenthalpic throttling, e.g. JT valve, regulating valve or venturi, or isentropic nozzle, e.g. Laval
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/02—Internal refrigeration with liquid vaporising loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2270/00—Refrigeration techniques used
    • F25J2270/12—External refrigeration with liquid vaporising loop
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/12—Particular process parameters like pressure, temperature, ratios
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES
    • F25J—LIQUEFACTION, SOLIDIFICATION OR SEPARATION OF GASES OR GASEOUS OR LIQUEFIED GASEOUS MIXTURES BY PRESSURE AND COLD TREATMENT OR BY BRINGING THEM INTO THE SUPERCRITICAL STATE
    • F25J2290/00—Other details not covered by groups F25J2200/00 - F25J2280/00
    • F25J2290/40—Vertical layout or arrangement of cold equipments within in the cold box, e.g. columns, condensers, heat exchangers etc.

Definitions

  • This invention relates to a process and an apparatus for the separation of a gas containing hydrocarbons.
  • Ethylene, ethane, propylene, propane, and/or heavier hydrocarbons can be recovered from a variety of gases, such as natural gas, refinery gas, and synthetic gas streams obtained from other hydrocarbon materials such as coal, crude oil, naphtha, oil shale, tar sands, and lignite.
  • Natural gas usually has a major proportion of methane and ethane, i.e., methane and ethane together comprise at least 50 mole percent of the gas.
  • the gas also contains relatively lesser amounts of heavier hydrocarbons such as propane, butanes, pentanes, and the like, as well as hydrogen, nitrogen, carbon dioxide, and other gases.
  • the present invention is generally concerned with the recovery of ethylene, ethane, propylene, propane and heavier hydrocarbons from such gas streams.
  • a typical analysis of a gas stream to be processed in accordance with this invention would be, in approximate mole percent, 90.5% methane, 4.1% ethane and other C 2 components, 1.3% propane and other C 3 components, 0.4% iso-butane, 0.3% normal butane, and 0.5% pentanes plus, with the balance made up of nitrogen and carbon dioxide. Sulfur containing gases are also sometimes present.
  • a feed gas stream under pressure is cooled by heat exchange with other streams of the process and/or external sources of refrigeration such as a propane compression-refrigeration system.
  • liquids may be condensed and collected in one or more separators as high-pressure liquids containing some of the desired C 2 + components.
  • the high-pressure liquids may be expanded to a lower pressure and fractionated. The vaporization occurring during expansion of the liquids results in further cooling of the stream. Under some conditions, pre-cooling the high pressure liquids prior to the expansion may be desirable in order to further lower the temperature resulting from the expansion.
  • the expanded stream comprising a mixture of liquid and vapor, is fractionated in a distillation (demethanizer or deethanizer) column.
  • the expansion cooled stream(s) is (are) distilled to separate residual methane, nitrogen, and other volatile gases as overhead vapor from the desired C 2 components, C 3 components, and heavier hydrocarbon components as bottom liquid product, or to separate residual methane, C 2 components, nitrogen, and other volatile gases as overhead vapor from the desired C 3 components and heavier hydrocarbon components as bottom liquid product.
  • the vapor remaining from the partial condensation can be split into two streams.
  • One portion of the vapor is passed through a work expansion machine or engine, or an expansion valve, to a lower pressure at which additional liquids are condensed as a result of further cooling of the stream.
  • the pressure after expansion is essentially the same as the pressure at which the distillation column is operated.
  • the combined vapor-liquid phases resulting from the expansion are supplied as feed to the column.
  • the remaining portion of the vapor is cooled to substantial condensation by heat exchange with other process streams, e.g., the cold fractionation tower overhead.
  • Some or all of the high-pressure liquid may be combined with this vapor portion prior to cooling.
  • the resulting cooled stream is then expanded through an appropriate expansion device, such as an expansion valve, to the pressure at which the demethanizer is operated. During expansion, a portion of the liquid will vaporize, resulting in cooling of the total stream.
  • the flash expanded stream is then supplied as top feed to the demethanizer.
  • the vapor portion of the flash expanded stream and the demethanizer overhead vapor combine in an upper separator section in the fractionation tower as residual methane product gas.
  • the cooled and expanded stream may be supplied to a separator to provide vapor and liquid streams.
  • the vapor is combined with the tower overhead and the liquid is supplied to the column as a top column feed.
  • the residue gas leaving the process will contain substantially all of the methane in the feed gas with essentially none of the heavier hydrocarbon components, and the bottoms fraction leaving the demethanizer will contain substantially all of the heavier hydrocarbon components with essentially no methane or more volatile components.
  • this ideal situation is not obtained because the conventional demethanizer is operated largely as a stripping column.
  • the methane product of the process therefore, typically comprises vapors leaving the top fractionation stage of the column, together with vapors not subjected to any rectification step.
  • the preferred processes for hydrocarbon separation use an upper absorber section to provide additional rectification of the rising vapors.
  • the source of the reflux stream for the upper rectification section is typically a recycled stream of residue gas supplied under pressure.
  • the recycled residue gas stream is usually cooled to substantial condensation by heat exchange with other process streams, e.g., the cold fractionation tower overhead.
  • the resulting substantially condensed stream is then expanded through an appropriate expansion device, such as an expansion valve, to the pressure at which the demethanizer is operated. During expansion, a portion of the liquid will usually vaporize, resulting in cooling of the total stream.
  • the flash expanded stream is then supplied as top feed to the demethanizer.
  • the vapor portion of the expanded stream and the demethanizer overhead vapor combine in an upper separator section in the fractionation tower as residual methane product gas.
  • the cooled and expanded stream may be supplied to a separator to provide vapor and liquid streams, so that thereafter the vapor is combined with the tower overhead and the liquid is supplied to the column as a top column feed.
  • Typical process schemes of this type are disclosed in U.S. Pat. Nos. 4,889,545; 5,568,737; and 5,881,569, assignee's co-pending application Ser. No. 12/717,394, and in Mowrey, E.
  • the present invention also employs an upper rectification section (or a separate rectification column if plant size or other factors favor using separate rectification and stripping columns).
  • the reflux stream for this rectification section is provided by using a side draw of the vapors rising in a lower portion of the tower combined with a portion of the column overhead vapor. Because of the relatively high concentration of C 2 components in the vapors lower in the tower, a significant quantity of liquid can be condensed from this combined vapor stream with only a modest elevation in pressure, using the refrigeration available in the remaining portion of the cold overhead vapor leaving the upper rectification section of the column to provide most of the cooling.
  • This condensed liquid which is predominantly liquid methane, can then be used to absorb C 2 components, C 3 components, C 4 components, and heavier hydrocarbon components from the vapors rising through the upper rectification section and thereby capture these valuable components in the bottom liquid product from the demethanizer.
  • the present invention makes possible essentially 100% separation of methane and lighter components from the C 2 components and heavier components at lower energy requirements compared to the prior art while maintaining the recovery levels.
  • the present invention although applicable at lower pressures and warmer temperatures, is particularly advantageous when processing feed gases in the range of 400 to 1500 psia [2,758 to 10,342 kPa(a)] or higher under conditions requiring NGL recovery column overhead temperatures of ⁇ 50° F. [ ⁇ 46° C.] or colder.
  • FIG. 1 is a flow diagram of a prior art natural gas processing plant in accordance with assignee's co-pending application Ser. No. 11/839,693;
  • FIG. 2 is a flow diagram of a natural gas processing plant in accordance with the present invention.
  • FIGS. 3 through 6 are flow diagrams illustrating alternative means of application of the present invention to a natural gas stream.
  • FIG. 1 is a process flow diagram showing the design of a processing plant to recover C 2 + components from natural gas using prior art according to assignee's co-pending application Ser. No. 11/839,693.
  • inlet gas enters the plant at 120° F. [49° C.] and 1025 psia [7,067 kPa(a)] as stream 31 .
  • the sulfur compounds are removed by appropriate pretreatment of the feed gas (not illustrated).
  • the feed stream is usually dehydrated to prevent hydrate (ice) formation under cryogenic conditions. Solid desiccant has typically been used for this purpose.
  • the feed stream 31 is cooled in heat exchanger 10 by heat exchange with cool residue gas (stream 41 b ), demethanizer reboiler liquids at 51° F. [11° C.] (stream 44 ), demethanizer lower side reboiler liquids at 10° F. [ ⁇ 12° C.] (stream 43 ), and demethanizer upper side reboiler liquids at ⁇ 65° F. [ ⁇ 54° C.] (stream 42 ).
  • stream 41 b cool residue gas
  • stream 44 demethanizer lower side reboiler liquids at 10° F. [ ⁇ 12° C.]
  • demethanizer upper side reboiler liquids at ⁇ 65° F. [ ⁇ 54° C.]
  • the cooled stream 31 a enters separator 11 at ⁇ 38° F. [ ⁇ 39° C.] and 1015 psia [6,998 kPa(a)] where the vapor (stream 32 ) is separated from the condensed liquid (stream 33 ).
  • the separator liquid (stream 33 ) is expanded to the operating pressure (approximately 465 psia [3,208 kPa(a)]) of fractionation tower 18 by expansion valve 17 , cooling stream 33 a to ⁇ 67° F. [ ⁇ 55° C.] before it is supplied to fractionation tower 18 at a lower mid-column feed point.
  • the vapor (stream 32 ) from separator 11 is divided into two streams, 36 and 39 .
  • Stream 36 containing about 23% of the total vapor, passes through heat exchanger 12 in heat exchange relation with the cold residue gas (stream 41 a ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 36 a at ⁇ 102° F. [ ⁇ 74° C.] is then flash expanded through expansion valve 14 to slightly above the operating pressure of fractionation tower 18 . During expansion a portion of the stream is vaporized, resulting in cooling of the total stream.
  • the expanded stream 36 b leaving expansion valve 14 reaches a temperature of ⁇ 127° F. [ ⁇ 88° C.] before it is supplied at an upper mid-column feed point, in absorbing section 18 a of fractionation tower 18 .
  • the remaining 77% of the vapor from separator 11 enters a work expansion machine 15 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 15 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 39 a to a temperature of approximately ⁇ 101° F. [ ⁇ 74° C.].
  • the typical commercially available expanders are capable of recovering on the order of 80-85% of the work theoretically available in an ideal isentropic expansion.
  • the work recovered is often used to drive a centrifugal compressor (such as item 16 ) that can be used to re-compress the residue gas (stream 41 c ), for example.
  • the partially condensed expanded stream 39 a is thereafter supplied as feed to fractionation tower 18 at a mid-column feed point.
  • the demethanizer in tower 18 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing.
  • the demethanizer tower consists of two sections: an upper absorbing (rectification) section 18 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 36 b and 39 a rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components; and a lower, stripping section 18 b that contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward.
  • an upper absorbing (rectification) section 18 a that contains the trays and/or packing to provide the necessary contact between the vapor portions of the expanded streams 36 b and 39 a rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components
  • a lower, stripping section 18 b that contains the trays and/or
  • the demethanizing section 18 b also includes one or more reboilers (such as the reboiler and side reboilers described previously) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column to strip the liquid product, stream 45 , of methane and lighter components.
  • Stream 39 a enters demethanizer 18 at an intermediate feed position located in the lower region of absorbing section 18 a of demethanizer 18 .
  • the liquid portion of the expanded stream 39 a comingles with liquids falling downward from absorbing section 18 a and the combined liquid continues downward into stripping section 18 b of demethanizer 18 .
  • the vapor portion of the expanded stream 39 a rises upward through absorbing section 18 a and is contacted with cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components.
  • a portion of the distillation vapor (stream 48 ) is withdrawn from an intermediate region of absorbing section 18 a in fractionation column 18 , above the feed position of expanded stream 39 a and below the feed position of expanded stream 36 b .
  • the distillation vapor stream 48 at ⁇ 113° F. [ ⁇ 81° C.] is compressed to 604 psia [4,165 kPa(a)] (stream 48 a ) by reflux compressor 21 , then cooled from ⁇ 84° F. [ ⁇ 65° C.] to ⁇ 124° F. [ ⁇ 87° C.] and substantially condensed (stream 48 b ) in heat exchanger 22 by heat exchange with cold residue gas stream 41 , the overhead stream exiting the top of demethanizer 18 .
  • the substantially condensed stream 48 b is then expanded through an appropriate expansion device, such as expansion valve 23 , to the demethanizer operating pressure, resulting in cooling of the total stream to ⁇ 131° F. [ ⁇ 91° C.].
  • the expanded stream 48 c is then supplied to fractionation tower 18 as the top column feed.
  • the vapor portion of stream 48 c combines with the vapors rising from the top fractionation stage of the column to form demethanizer overhead stream 41 at ⁇ 128° F. [ ⁇ 89° C.].
  • the liquid product (stream 45 ) exits the bottom of tower 18 at 70° F. [21° C.], based on a typical specification of a methane to ethane ratio of 0.025:1 on a molar basis in the bottom product.
  • the cold residue gas stream 41 passes countercurrently to the compressed distillation vapor stream in heat exchanger 22 where it is heated to ⁇ 106° F. [ ⁇ 77° C.] (stream 41 a ), and countercurrently to the incoming feed gas in heat exchanger 12 where it is heated to ⁇ 66° F. [ ⁇ 55° C.] (stream 41 b ) and in heat exchanger 10 where it is heated to 110° F. [43° C.] (stream 41 c ).
  • the residue gas is then re-compressed in two stages.
  • the first stage is compressor 16 driven by expansion machine 15 .
  • the second stage is compressor 24 driven by a supplemental power source which compresses the residue gas (stream 41 e ) to sales line pressure.
  • the residue gas product (stream 41 f ) flows to the sales gas pipeline at 1025 psia [7,067 kPa(a)], sufficient to meet line requirements (usually on the order of the inlet pressure).
  • FIG. 2 illustrates a flow diagram of a process in accordance with the present invention.
  • the feed gas composition and conditions considered in the process presented in FIG. 2 are the same as those in FIG. 1 . Accordingly, the FIG. 2 process can be compared with that of the FIG. 1 process to illustrate the advantages of the present invention.
  • inlet gas enters the plant at 120° F. [49° C.] and 1025 psia [7,067 kPa(a)] as stream 31 and is cooled in heat exchanger 10 by heat exchange with cool residue gas (stream 46 b ), demethanizer reboiler liquids at 50° F. [10° C.] (stream 44 ), demethanizer lower side reboiler liquids at 8° F. [ ⁇ 13° C.] (stream 43 ), and demethanizer upper side reboiler liquids at ⁇ 67° F. [ ⁇ 55° C.] (stream 42 ).
  • the cooled stream 31 a enters separator 11 at ⁇ 38° F.
  • the vapor (stream 32 ) from separator 11 is divided into two streams, 34 and 39 .
  • Stream 34 containing about 26% of the total vapor, passes through heat exchanger 12 in heat exchange relation with the cold residue gas (stream 46 a ) where it is cooled to substantial condensation.
  • the resulting substantially condensed stream 36 a at ⁇ 106° F. [ ⁇ 76° C.] is then divided into two portions, streams 37 and 38 .
  • Stream 38 containing about 50.5% of the total substantially condensed stream, is flash expanded through expansion valve 14 to the operating pressure of fractionation tower 18 . During expansion a portion of the stream is vaporized, resulting in cooling of the total stream.
  • the expanded stream 38 a leaving expansion valve 14 reaches a temperature of ⁇ 127° F. [ ⁇ 88° C.] before it is supplied at an upper mid-column feed point, in absorbing section 18 a of fractionation tower 18 .
  • the remaining 49.5% of the substantially condensed stream (stream 37 ) is flash expanded through expansion valve 13 to slightly above the operating pressure of fractionation tower 18 .
  • the flash expanded stream 37 a is warmed slightly in heat exchanger 22 from ⁇ 126° F. [ ⁇ 88° C.] to ⁇ 125° F.
  • the remaining 74% of the vapor from separator 11 enters a work expansion machine 15 in which mechanical energy is extracted from this portion of the high pressure feed.
  • the machine 15 expands the vapor substantially isentropically to the tower operating pressure, with the work expansion cooling the expanded stream 39 a to a temperature of approximately ⁇ 100° F. [ ⁇ 73° C.].
  • the partially condensed expanded stream 39 a is thereafter supplied as feed to fractionation tower 18 at a mid-column feed point (located below the feed points of streams 38 a and 37 b ).
  • the demethanizer in tower 18 is a conventional distillation column containing a plurality of vertically spaced trays, one or more packed beds, or some combination of trays and packing.
  • the demethanizer tower consists of two sections: an upper absorbing (rectification) section 18 a that contains the trays and/or packing to provide the necessary contact between the vapor portion of the expanded streams 38 a and 39 a and heated expanded stream 37 b rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components from the vapors rising upward; and a lower, stripping section 18 b that contains the trays and/or packing to provide the necessary contact between the liquids falling downward and the vapors rising upward.
  • an upper absorbing (rectification) section 18 a that contains the trays and/or packing to provide the necessary contact between the vapor portion of the expanded streams 38 a and 39 a and heated expanded stream 37 b rising upward and cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier
  • the demethanizing section 18 b also includes one or more reboilers (such as the reboiler and side reboilers described previously) which heat and vaporize a portion of the liquids flowing down the column to provide the stripping vapors which flow up the column to strip the liquid product, stream 45 , of methane and lighter components.
  • Stream 39 a enters demethanizer 18 at an intermediate feed position located in the lower region of absorbing section 18 a of demethanizer 18 .
  • the liquid portion of the expanded stream comingles with liquids falling downward from absorbing section 18 a and the combined liquid continues downward into stripping section 18 b of demethanizer 18 .
  • the vapor portion of the expanded stream comingles with vapors arising from stripping section 18 b and the combined vapor rises upward through absorbing section 18 a and is contacted with cold liquid falling downward to condense and absorb the C 2 components, C 3 components, and heavier components.
  • a portion of the distillation vapor (stream 48 ) is withdrawn from an intermediate region of absorbing section 18 a in fractionation column 18 , above the feed position of expanded stream 39 a in the lower region of absorbing section 18 a and below the feed positions of expanded stream 38 a and heated expanded stream 37 b .
  • the distillation vapor stream 48 at ⁇ 116° F. [ ⁇ 82° C.] is combined with a portion (stream 47 ) of overhead vapor stream 41 at ⁇ 128° F. [ ⁇ 89° C.] to form combined vapor stream 49 at ⁇ 118° F. [ ⁇ 83° C.].
  • the combined vapor stream 49 is compressed to 592 psia [4,080 kPa(a)] (stream 49 a ) by reflux compressor 21 , then cooled from ⁇ 92° F. [ ⁇ 69° C.] to ⁇ 124° F. [ ⁇ 87° C.] and substantially condensed (stream 49 b ) in heat exchanger 22 by heat exchange with residue gas stream 46 (the remaining portion of cold demethanizer overhead stream 41 exiting the top of demethanizer 18 ) and with the flash expanded stream 37 a as described previously.
  • residue gas stream 46 the remaining portion of cold demethanizer overhead stream 41 exiting the top of demethanizer 18
  • the cold residue gas stream is warmed to ⁇ 110° F. [ ⁇ 79° C.] (stream 46 a ) as it provides cooling to the compressed combined vapor stream 49 a.
  • the substantially condensed stream 49 b is flash expanded to the operating pressure of demethanizer 18 by expansion valve 23 .
  • a portion of the stream is vaporized, further cooling stream 49 c to ⁇ 132° F. [ ⁇ 91° C.] before it is supplied as cold top column feed (reflux) to demethanizer 18 .
  • This cold liquid reflux absorbs and condenses the C 2 components, C 3 components, and heavier components rising in the upper rectification region of absorbing section 18 a of demethanizer 18 .
  • stream 45 exits the bottom of tower 18 at 68° F. [20° C.] (based on a typical specification of a methane to ethane ratio of 0.025:1 on a molar basis in the bottom product).
  • the partially warmed residue gas stream 46 a passes countercurrently to the incoming feed gas in heat exchanger 12 where it is heated to ⁇ 61° F. [ ⁇ 52° C.] (stream 46 b ) and in heat exchanger 10 where it is heated to 112° F. [44° C.] (stream 46 c ) as it provides cooling as previously described.
  • stream 46 e is cooled to 120° F. [49° C.] in discharge cooler 25
  • the residue gas product flows to the sales gas pipeline at 1025 psia [7,067 kPa(a)], sufficient to meet line requirements (usually on the order of the inlet pressure).
  • Tables I and II show that, compared to the prior art, the present invention improves ethane recovery from 83.06% to 84.98%, propane recovery from 99.50% to 99.67%, and butanes+recovery from 99.98% to 99.99%. Comparison of Tables I and II further shows that the improvement in yields was achieved using essentially the same power as the prior art. In terms of the recovery efficiency (defined by the quantity of ethane recovered per unit of power), the present invention represents a 2% improvement over the prior art of the FIG. 1 process.
  • the improvement in the recovery efficiency of the present invention over that of the prior art processes can be understood by examining the improvement in the rectification that the present invention provides for the upper region of absorbing section 18 a .
  • the present invention produces a better top reflux stream containing more methane and less C 2 + components. Comparing reflux stream 48 in Table I for the FIG. 1 prior art process with reflux stream 49 in Table II for the present invention, it can be seen that the present invention provides a reflux stream that is greater in quantity (nearly 8%) with a significantly lower concentration of C 2 + components (1.9% for the present invention versus 2.5% for the FIG. 1 prior art process).
  • the present invention uses a portion of substantially condensed feed stream 36 a (expanded stream 37 a ) to supplement the cooling provided by the residue gas (stream 46 ), the compressed reflux stream 49 a can be substantially condensed at lower pressure, reducing the power required by reflux compressor 21 compared to the FIG. 1 prior art process even though the reflux flow rate is higher for the present invention.
  • the present invention uses only a portion of substantially condensed feed stream 36 a (expanded stream 37 a ) to provide cooling to compressed reflux stream 49 a . This allows the rest of substantially condensed feed stream 36 a (expanded stream 38 a ) to provide bulk recovery of the C 2 components, C 3 components, and heavier hydrocarbon components contained in expanded feed 39 a and the vapors rising from stripping section 18 b .
  • the cold residue gas (stream 46 ) is used to provide most of the cooling of compressed reflux stream 49 a , reducing the heating of stream 37 a compared to the prior art so that the resulting stream 37 b can supplement the bulk recovery provided by expanded stream 38 a .
  • the supplemental rectification provided by reflux stream 49 c can then reduce the amount of C 2 components, C 3 components, and C 4 + components contained in the inlet feed gas that is lost to the residue gas.
  • the present invention also reduces the rectification required from reflux stream 49 c in absorbing section 18 a compared to the prior art U.S. Pat. No. 4,889,545 process by condensing reflux stream 49 c with less warming of the column feeds (streams 37 b , 38 a , and 39 a ) to absorbing section 18 a . If all of the substantially condensed stream 36 a is expanded and warmed to provide condensing as is taught in U.S. Pat. No. 4,889,545, not only is there less cold liquid in the resulting stream available for rectification of the vapors rising in absorbing section 18 a , there is much more vapor in the upper region of absorbing section 18 a that must be rectified by the reflux stream.
  • 4,889,545 process are that the cold residue gas stream 46 is used to provide most of the cooling of compressed reflux stream 49 a in heat exchanger 22 , and that the distillation vapor stream 48 contains a significant fraction of C 2 components not found in the column overhead stream 41 , allowing sufficient methane to be condensed for use as reflux without adding significant rectification load in absorbing section 18 a due to the excessive vaporization of stream 36 a that is inherent when it is expanded and heated as taught in the U.S. Pat. No. 4,889,545 prior art process.
  • the absorbing (rectification) section of the demethanizer it is generally advantageous to design the absorbing (rectification) section of the demethanizer to contain multiple theoretical separation stages.
  • the benefits of the present invention can be achieved with as few as two theoretical stages.
  • all or a part of the expanded reflux stream (stream 49 c ) leaving expansion valve 23 , all or a part of the expanded substantially condensed stream 38 a from expansion valve 14 , and all or a part of the heated expanded stream 37 b leaving heat exchanger 22 can be combined (such as in the piping joining the expansion valves and heat exchanger to the demethanizer) and if thoroughly intermingled, the vapors and liquids will mix together and separate in accordance with the relative volatilities of the various components of the total combined streams.
  • Such comingling of the three streams, combined with contacting at least a portion of expanded stream 39 a shall be considered for the purposes of this invention as constituting an absorbing section.
  • FIGS. 3 through 6 display other embodiments of the present invention.
  • FIGS. 2 through 4 depict fractionation towers constructed in a single vessel.
  • FIGS. 5 and 6 depict fractionation towers constructed in two vessels, absorber (rectifier) column 18 (a contacting and separating device) and stripper (distillation) column 20 .
  • the overhead vapor stream 54 from stripper column 20 flows to the lower section of absorber column 18 (via stream 55 ) to be contacted by reflux stream 49 c , expanded substantially condensed stream 38 a , and heated expanded stream 37 b .
  • Pump 19 is used to route the liquids (stream 53 ) from the bottom of absorber column 18 to the top of stripper column 20 so that the two towers effectively function as one distillation system.
  • the decision whether to construct the fractionation tower as a single vessel (such as demethanizer 18 in FIGS. 2 through 4 ) or multiple vessels will depend on a number of factors such as plant size, the distance to fabrication facilities, etc.
  • distillation vapor stream 48 in FIGS. 3 and 4 may be withdrawn from absorber column 18 above the feed point of expanded substantially condensed stream 38 a (stream 50 ) or below the feed point of expanded substantially condensed stream 38 a (stream 51 ).
  • the compressed combined vapor stream 49 a is substantially condensed and the resulting condensate used to absorb valuable C 2 components, C 3 components, and heavier components from the vapors rising through absorbing section 18 a of demethanizer 18 or through absorber column 18 .
  • the present invention is not limited to this embodiment. It may be advantageous, for instance, to treat only a portion of these vapors in this manner, or to use only a portion of the condensate as an absorbent, in cases where other design considerations indicate portions of the vapors or the condensate should bypass absorbing section 18 a of demethanizer 18 or absorber column 18 . Some circumstances may favor partial condensation, rather than substantial condensation, of compressed combined vapor stream 49 a in heat exchanger 22 .
  • distillation vapor stream 48 be a total vapor side draw from fractionation column 18 or absorber column 18 rather than a partial vapor side draw. It should also be noted that, depending on the composition of the feed gas stream, it may be advantageous to use external refrigeration to provide partial cooling of compressed combined vapor stream 49 a in heat exchanger 22 .
  • Feed gas conditions, plant size, available equipment, or other factors may indicate that elimination of work expansion machine 15 , or replacement with an alternate expansion device (such as an expansion valve), is feasible.
  • an alternate expansion device such as an expansion valve
  • alternative expansion means may be employed where appropriate. For example, conditions may warrant work expansion of the substantially condensed portions of the feed stream (streams 37 and 38 ) or the substantially condensed reflux stream leaving heat exchanger 22 (stream 49 b ).
  • the cooled feed stream 31 a leaving heat exchanger 10 in FIGS. 2 through 6 may not contain any liquid (because it is above its dewpoint, or because it is above its cricondenbar). In such cases, separator 11 shown in FIGS. 2 through 6 is not required.
  • the splitting of the vapor feed may be accomplished in several ways. In the processes of FIGS. 2, 3, and 5 , the splitting of vapor occurs following cooling and separation of any liquids which may have been formed. The high pressure gas may be split, however, prior to any cooling of the inlet gas as shown in FIGS. 4 and 6 . In some embodiments, vapor splitting may be effected in a separator.
  • the high pressure liquid (stream 33 in FIGS. 2 through 6 ) need not be expanded and fed to a mid-column feed point on the distillation column. Instead, all or a portion of it may be combined with the portion of the separator vapor (stream 34 in FIGS. 2, 3, and 5 ) or the portion of the cooled feed gas (stream 34 a in FIGS. 4 and 6 ) flowing to heat exchanger 12 . (This is shown by the dashed stream 35 in FIGS. 2 through 6 .) Any remaining portion of the liquid may be expanded through an appropriate expansion device, such as an expansion valve or expansion machine, and fed to a mid-column feed point on the distillation column (stream 40 a in FIGS. 2 through 6 ). Stream 40 may also be used for inlet gas cooling or other heat exchange service before or after the expansion step prior to flowing to the demethanizer.
  • the use of external refrigeration to supplement the cooling available to the inlet gas from other process streams may be employed, particularly in the case of a rich inlet gas.
  • the use and distribution of separator liquids and demethanizer side draw liquids for process heat exchange, and the particular arrangement of heat exchangers for inlet gas cooling must be evaluated for each particular application, as well as the choice of process streams for specific heat exchange services.
  • the relative amount of feed found in each branch of the split vapor feed will depend on several factors, including gas pressure, feed gas composition, the amount of heat which can economically be extracted from the feed, and the quantity of horsepower available. More feed to the top of the column may increase recovery while decreasing power recovered from the expander thereby increasing the recompression horsepower requirements. Increasing feed lower in the column reduces the horsepower consumption but may also reduce product recovery.
  • the relative locations of the mid-column feeds may vary depending on inlet composition or other factors such as desired recovery levels and amount of liquid formed during inlet gas cooling.
  • two or more of the feed streams, or portions thereof may be combined depending on the relative temperatures and quantities of individual streams, and the combined stream then fed to a mid-column feed position.
  • circumstances may favor combining expanded substantially condensed stream 38 a with heated expanded stream 37 b and supplying the combined stream to a single upper mid-column feed point on fractionation tower 18 ( FIGS. 2 through 4 ) or absorber column 18 ( FIGS. 5 and 6 ).
  • the present invention provides improved recovery of C 2 components, C 3 components, and heavier hydrocarbon components or of C 3 components and heavier hydrocarbon components per amount of utility consumption required to operate the process.
  • An improvement in utility consumption required for operating the demethanizer or deethanizer process may appear in the form of reduced power requirements for compression or re-compression, reduced power requirements for external refrigeration, reduced energy requirements for tower reboilers, or a combination thereof.

Landscapes

  • Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Mechanical Engineering (AREA)
  • Thermal Sciences (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Chemical & Material Sciences (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Vaporization, Distillation, Condensation, Sublimation, And Cold Traps (AREA)
US12/869,007 2009-09-21 2010-08-26 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column Active 2034-04-23 US9476639B2 (en)

Priority Applications (59)

Application Number Priority Date Filing Date Title
US12/869,007 US9476639B2 (en) 2009-09-21 2010-08-26 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column
PE2012000349A PE20121422A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
KR1020127009963A KR101619568B1 (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
EP10817650A EP2480845A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
EA201200524A EA021947B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
BR112012006279A BR112012006279A2 (pt) 2009-09-21 2010-08-27 processamento de gás de hidrocarboneto
JP2012529779A JP5793144B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
PCT/US2010/046953 WO2011034709A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
EA201200521A EA028835B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
BR112012006219A BR112012006219A2 (pt) 2009-09-21 2010-08-27 processamento de hicrocarbonetos gasosos.
NZ599331A NZ599331A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
JP2012529781A JP5793145B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
PE2012000352A PE20121420A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
NZ599333A NZ599333A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
SG2012014452A SG178933A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CA2772972A CA2772972C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
EP10817651A EP2480846A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CN201080041904.9A CN102498360B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
CN201080041508.6A CN102498359B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
EP10825365.9A EP2480847A4 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
NZ599335A NZ599335A (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CA2773211A CA2773211C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
PCT/US2010/046967 WO2011049672A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
EA201200520A EA024075B1 (ru) 2009-09-21 2010-08-27 Переработка углеводородного газа
MX2012002969A MX2012002969A (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
PCT/US2010/046966 WO2011034710A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
PE2012000351A PE20121421A1 (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos
SG2012014445A SG178603A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
JP2012529780A JP5850838B2 (ja) 2009-09-21 2010-08-27 炭化水素ガス処理
AU2010308519A AU2010308519B2 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
KR1020127009964A KR20120072373A (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
MX2012002970A MX351303B (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
AU2010295870A AU2010295870A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
BR112012006277A BR112012006277A2 (pt) 2009-09-21 2010-08-27 processamento de hidrocarbonetos gasosos
SG2012015392A SG178989A1 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
CA2773157A CA2773157C (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
KR1020127009836A KR20120069729A (ko) 2009-09-21 2010-08-27 탄화수소 가스 처리공정
CN201080041905.3A CN102575898B (zh) 2009-09-21 2010-08-27 碳氢化合物气体处理
MX2012002971A MX348674B (es) 2009-09-21 2010-08-27 Procesamiento de gases de hidrocarburos.
AU2010295869A AU2010295869B2 (en) 2009-09-21 2010-08-27 Hydrocarbon gas processing
TW099131475A TW201111725A (en) 2009-09-21 2010-09-16 Hydrocarbon gas processing
TW099131477A TW201127471A (en) 2009-09-21 2010-09-16 Hydrocarbon gas processing
TW099131479A TWI477595B (zh) 2009-09-21 2010-09-16 碳氫化合物氣體處理
SA110310707A SA110310707B1 (ar) 2009-09-21 2010-09-20 معالجة غاز هيدروكربونى
SA110310705A SA110310705B1 (ar) 2009-09-21 2010-09-20 معالجة غاز هيدروكربونى
SA110310706A SA110310706B1 (ar) 2009-09-21 2010-09-20 معالجة غازهيدروكربونى
ARP100103435 AR078403A1 (es) 2010-05-19 2010-09-21 Procesamiento de gases de hidrocarburos
ARP100103434A AR078402A1 (es) 2009-09-21 2010-09-21 Procesamiento de gases de hidrocarburos
ARP100103433A AR078401A1 (es) 2009-09-21 2010-09-21 Procesamiento de gases de hidrocarburos
EG2012030439A EG26970A (en) 2009-09-21 2012-03-11 Hydrocarbon gas processing
EG2012030437A EG27017A (en) 2009-09-21 2012-03-12 Hydrocarbon gas processing
CL2012000687A CL2012000687A1 (es) 2009-09-21 2012-03-19 Proceso y aparato para separar una corriente de gas que contiene metano, c2, c3 e hidrocarburos más pesados en una fracción de gas residual volatil y una fraccion relativamente menos volatil.
ZA2012/02634A ZA201202634B (en) 2009-09-21 2012-04-12 Hydrocarbon gas processing
ZA2012/02633A ZA201202633B (en) 2009-09-21 2012-04-12 Hydrocarbon gas processing
ZA2012/02696A ZA201202696B (en) 2009-09-21 2012-04-13 Hydrocarbon gas processing
CO12064992A CO6531456A2 (es) 2009-09-21 2012-04-19 Procesamiento de gases de hidrocarburos
CO12064988A CO6531455A2 (es) 2009-09-21 2012-04-19 Procesamiento de gases de hidrocarburos
CO12065754A CO6531461A2 (es) 2009-09-21 2012-04-20 Procesamiento de gases de hidrocarburos
US15/259,891 US20160377341A1 (en) 2009-09-21 2016-09-08 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US24418109P 2009-09-21 2009-09-21
US34615010P 2010-05-19 2010-05-19
US35104510P 2010-06-03 2010-06-03
US12/869,007 US9476639B2 (en) 2009-09-21 2010-08-26 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US15/259,891 Division US20160377341A1 (en) 2009-09-21 2016-09-08 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column

Publications (2)

Publication Number Publication Date
US20110067442A1 US20110067442A1 (en) 2011-03-24
US9476639B2 true US9476639B2 (en) 2016-10-25

Family

ID=43755438

Family Applications (4)

Application Number Title Priority Date Filing Date
US12/868,993 Abandoned US20110067441A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing
US12/869,007 Active 2034-04-23 US9476639B2 (en) 2009-09-21 2010-08-26 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column
US12/869,139 Abandoned US20110067443A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing
US15/259,891 Abandoned US20160377341A1 (en) 2009-09-21 2016-09-08 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column

Family Applications Before (1)

Application Number Title Priority Date Filing Date
US12/868,993 Abandoned US20110067441A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing

Family Applications After (2)

Application Number Title Priority Date Filing Date
US12/869,139 Abandoned US20110067443A1 (en) 2009-09-21 2010-08-26 Hydrocarbon Gas Processing
US15/259,891 Abandoned US20160377341A1 (en) 2009-09-21 2016-09-08 Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column

Country Status (22)

Country Link
US (4) US20110067441A1 (ar)
EP (3) EP2480847A4 (ar)
JP (3) JP5793145B2 (ar)
KR (3) KR20120072373A (ar)
CN (3) CN102498360B (ar)
AR (2) AR078401A1 (ar)
AU (3) AU2010295870A1 (ar)
BR (3) BR112012006219A2 (ar)
CA (3) CA2772972C (ar)
CL (3) CL2012000687A1 (ar)
CO (3) CO6531455A2 (ar)
EA (3) EA024075B1 (ar)
EG (2) EG26970A (ar)
MX (3) MX351303B (ar)
MY (3) MY163645A (ar)
NZ (3) NZ599331A (ar)
PE (3) PE20121420A1 (ar)
SA (3) SA110310706B1 (ar)
SG (3) SG178989A1 (ar)
TW (3) TWI477595B (ar)
WO (3) WO2011049672A1 (ar)
ZA (2) ZA201202633B (ar)

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10533794B2 (en) 2016-08-26 2020-01-14 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US10551118B2 (en) 2016-08-26 2020-02-04 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US10551119B2 (en) 2016-08-26 2020-02-04 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US11428465B2 (en) 2017-06-01 2022-08-30 Uop Llc Hydrocarbon gas processing
US11543180B2 (en) 2017-06-01 2023-01-03 Uop Llc Hydrocarbon gas processing
US11578915B2 (en) 2019-03-11 2023-02-14 Uop Llc Hydrocarbon gas processing
US11643604B2 (en) 2019-10-18 2023-05-09 Uop Llc Hydrocarbon gas processing

Families Citing this family (48)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN100565061C (zh) * 2003-10-30 2009-12-02 弗劳尔科技公司 柔性液态天然气工艺和方法
US7777088B2 (en) 2007-01-10 2010-08-17 Pilot Energy Solutions, Llc Carbon dioxide fractionalization process
US20090282865A1 (en) 2008-05-16 2009-11-19 Ortloff Engineers, Ltd. Liquefied Natural Gas and Hydrocarbon Gas Processing
US20100287982A1 (en) 2009-05-15 2010-11-18 Ortloff Engineers, Ltd. Liquefied Natural Gas and Hydrocarbon Gas Processing
US20110067441A1 (en) * 2009-09-21 2011-03-24 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US9021832B2 (en) * 2010-01-14 2015-05-05 Ortloff Engineers, Ltd. Hydrocarbon gas processing
CN102933273B (zh) 2010-06-03 2015-05-13 奥特洛夫工程有限公司 碳氢化合物气体处理
US10451344B2 (en) 2010-12-23 2019-10-22 Fluor Technologies Corporation Ethane recovery and ethane rejection methods and configurations
US9767421B2 (en) 2011-10-26 2017-09-19 QRI Group, LLC Determining and considering petroleum reservoir reserves and production characteristics when valuing petroleum production capital projects
US20130110474A1 (en) 2011-10-26 2013-05-02 Nansen G. Saleri Determining and considering a premium related to petroleum reserves and production characteristics when valuing petroleum production capital projects
US10508520B2 (en) 2011-10-26 2019-12-17 QRI Group, LLC Systems and methods for increasing recovery efficiency of petroleum reservoirs
US9946986B1 (en) 2011-10-26 2018-04-17 QRI Group, LLC Petroleum reservoir operation using geotechnical analysis
US9710766B2 (en) * 2011-10-26 2017-07-18 QRI Group, LLC Identifying field development opportunities for increasing recovery efficiency of petroleum reservoirs
KR101368797B1 (ko) * 2012-04-03 2014-03-03 삼성중공업 주식회사 천연가스 분별증류 장치
CA2790961C (en) * 2012-05-11 2019-09-03 Jose Lourenco A method to recover lpg and condensates from refineries fuel gas streams.
CA2813260C (en) * 2013-04-15 2021-07-06 Mackenzie Millar A method to produce lng
PE20160478A1 (es) 2013-09-11 2016-05-13 Sme Products Lp Procesamiento de hidrocarburos gaseosos
RU2674807C2 (ru) 2013-09-11 2018-12-13 Ортлофф Инджинирс, Лтд. Обработка газообразных углеводородов
WO2015038288A1 (en) 2013-09-11 2015-03-19 Ortloff Engineers, Ltd. Hydrocarbon processing
WO2015103403A1 (en) * 2014-01-02 2015-07-09 Fluor Technologies Corporation Systems and methods for flexible propane recovery
US9945703B2 (en) 2014-05-30 2018-04-17 QRI Group, LLC Multi-tank material balance model
CA2958091C (en) 2014-08-15 2021-05-18 1304338 Alberta Ltd. A method of removing carbon dioxide during liquid natural gas production from natural gas at gas pressure letdown stations
US10508532B1 (en) 2014-08-27 2019-12-17 QRI Group, LLC Efficient recovery of petroleum from reservoir and optimized well design and operation through well-based production and automated decline curve analysis
CN104263402A (zh) * 2014-09-19 2015-01-07 华南理工大学 一种利用能量集成高效回收管输天然气中轻烃的方法
US10808999B2 (en) * 2014-09-30 2020-10-20 Dow Global Technologies Llc Process for increasing ethylene and propylene yield from a propylene plant
NO3029019T3 (ar) * 2014-12-05 2018-03-03
CA2881949C (en) * 2015-02-12 2023-08-01 Mackenzie Millar A method to produce plng and ccng at straddle plants
CN106278782A (zh) * 2015-05-29 2017-01-04 汪上晓 碳五产物分离装置
US11173445B2 (en) 2015-09-16 2021-11-16 1304338 Alberta Ltd. Method of preparing natural gas at a gas pressure reduction stations to produce liquid natural gas (LNG)
FR3042984B1 (fr) * 2015-11-03 2019-07-19 L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Optimisation d’un procede de deazotation d’un courant de gaz naturel
FR3042983B1 (fr) * 2015-11-03 2017-10-27 Air Liquide Reflux de colonnes de demethanisation
US10006701B2 (en) 2016-01-05 2018-06-26 Fluor Technologies Corporation Ethane recovery or ethane rejection operation
US10330382B2 (en) 2016-05-18 2019-06-25 Fluor Technologies Corporation Systems and methods for LNG production with propane and ethane recovery
US10458207B1 (en) 2016-06-09 2019-10-29 QRI Group, LLC Reduced-physics, data-driven secondary recovery optimization
US11402155B2 (en) * 2016-09-06 2022-08-02 Lummus Technology Inc. Pretreatment of natural gas prior to liquefaction
MX2019001888A (es) * 2016-09-09 2019-06-03 Fluor Tech Corp Metodos y configuracion para readaptacion de planta liquidos de gas (ngl) para alta recuperacion de etano.
GB2556878A (en) * 2016-11-18 2018-06-13 Costain Oil Gas & Process Ltd Hydrocarbon separation process and apparatus
WO2019019034A1 (zh) * 2017-07-26 2019-01-31 深圳市宏事达能源科技有限公司 一种气体分馏装置
US11112175B2 (en) 2017-10-20 2021-09-07 Fluor Technologies Corporation Phase implementation of natural gas liquid recovery plants
US11262123B2 (en) 2017-12-15 2022-03-01 Saudi Arabian Oil Company Process integration for natural gas liquid recovery
US11466554B2 (en) 2018-03-20 2022-10-11 QRI Group, LLC Data-driven methods and systems for improving oil and gas drilling and completion processes
US11506052B1 (en) 2018-06-26 2022-11-22 QRI Group, LLC Framework and interface for assessing reservoir management competency
US11015865B2 (en) * 2018-08-27 2021-05-25 Bcck Holding Company System and method for natural gas liquid production with flexible ethane recovery or rejection
US12098882B2 (en) 2018-12-13 2024-09-24 Fluor Technologies Corporation Heavy hydrocarbon and BTEX removal from pipeline gas to LNG liquefaction
RU2726329C1 (ru) * 2019-01-09 2020-07-13 Андрей Владиславович Курочкин Установка нтдр для деэтанизации природного газа (варианты)
RU2726328C1 (ru) * 2019-01-09 2020-07-13 Андрей Владиславович Курочкин Установка деэтанизации природного газа по технологии нтдр (варианты)
CN110746259B (zh) * 2019-08-24 2020-10-02 西南石油大学 一种带闪蒸分离器的富气乙烷回收方法
AR121085A1 (es) * 2020-01-24 2022-04-13 Lummus Technology Inc Proceso de recuperación de hidrocarburos a partir de corrientes de reflujo múltiples

Citations (52)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US33408A (en) 1861-10-01 Improvement in machinery for washing wool
US2952984A (en) 1958-06-23 1960-09-20 Conch Int Methane Ltd Processing liquefied natural gas
US3292380A (en) 1964-04-28 1966-12-20 Coastal States Gas Producing C Method and equipment for treating hydrocarbon gases for pressure reduction and condensate recovery
US3837172A (en) 1972-06-19 1974-09-24 Synergistic Services Inc Processing liquefied natural gas to deliver methane-enriched gas at high pressure
US4061481A (en) 1974-10-22 1977-12-06 The Ortloff Corporation Natural gas processing
US4140504A (en) 1976-08-09 1979-02-20 The Ortloff Corporation Hydrocarbon gas processing
US4157904A (en) 1976-08-09 1979-06-12 The Ortloff Corporation Hydrocarbon gas processing
US4171964A (en) 1976-06-21 1979-10-23 The Ortloff Corporation Hydrocarbon gas processing
US4185978A (en) 1977-03-01 1980-01-29 Standard Oil Company (Indiana) Method for cryogenic separation of carbon dioxide from hydrocarbons
US4251249A (en) 1977-01-19 1981-02-17 The Randall Corporation Low temperature process for separating propane and heavier hydrocarbons from a natural gas stream
US4278457A (en) 1977-07-14 1981-07-14 Ortloff Corporation Hydrocarbon gas processing
US4519824A (en) 1983-11-07 1985-05-28 The Randall Corporation Hydrocarbon gas separation
US4617039A (en) 1984-11-19 1986-10-14 Pro-Quip Corporation Separating hydrocarbon gases
US4687499A (en) 1986-04-01 1987-08-18 Mcdermott International Inc. Process for separating hydrocarbon gas constituents
US4689063A (en) 1985-03-05 1987-08-25 Compagnie Francaise D'etudes Et De Construction "Technip" Process of fractionating gas feeds and apparatus for carrying out the said process
US4690702A (en) 1984-09-28 1987-09-01 Compagnie Francaise D'etudes Et De Construction "Technip" Method and apparatus for cryogenic fractionation of a gaseous feed
US4854955A (en) 1988-05-17 1989-08-08 Elcor Corporation Hydrocarbon gas processing
US4869740A (en) 1988-05-17 1989-09-26 Elcor Corporation Hydrocarbon gas processing
US4889545A (en) 1988-11-21 1989-12-26 Elcor Corporation Hydrocarbon gas processing
US5114451A (en) 1990-03-12 1992-05-19 Elcor Corporation Liquefied natural gas processing
US5275005A (en) 1992-12-01 1994-01-04 Elcor Corporation Gas processing
US5555748A (en) 1995-06-07 1996-09-17 Elcor Corporation Hydrocarbon gas processing
US5566554A (en) 1995-06-07 1996-10-22 Kti Fish, Inc. Hydrocarbon gas separation process
US5568737A (en) 1994-11-10 1996-10-29 Elcor Corporation Hydrocarbon gas processing
US5771712A (en) 1995-06-07 1998-06-30 Elcor Corporation Hydrocarbon gas processing
US5799507A (en) 1996-10-25 1998-09-01 Elcor Corporation Hydrocarbon gas processing
US5881569A (en) 1997-05-07 1999-03-16 Elcor Corporation Hydrocarbon gas processing
US5890378A (en) 1997-04-21 1999-04-06 Elcor Corporation Hydrocarbon gas processing
US5983664A (en) 1997-04-09 1999-11-16 Elcor Corporation Hydrocarbon gas processing
US6182469B1 (en) 1998-12-01 2001-02-06 Elcor Corporation Hydrocarbon gas processing
US6578379B2 (en) 2000-12-13 2003-06-17 Technip-Coflexip Process and installation for separation of a gas mixture containing methane by distillation
US6604380B1 (en) 2002-04-03 2003-08-12 Howe-Baker Engineers, Ltd. Liquid natural gas processing
US6712880B2 (en) 2001-03-01 2004-03-30 Abb Lummus Global, Inc. Cryogenic process utilizing high pressure absorber column
US6907752B2 (en) 2003-07-07 2005-06-21 Howe-Baker Engineers, Ltd. Cryogenic liquid natural gas recovery process
US6915662B2 (en) 2000-10-02 2005-07-12 Elkcorp. Hydrocarbon gas processing
US7069743B2 (en) 2002-02-20 2006-07-04 Eric Prim System and method for recovery of C2+ hydrocarbons contained in liquefied natural gas
US20060283207A1 (en) 2005-06-20 2006-12-21 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US7155931B2 (en) 2003-09-30 2007-01-02 Ortloff Engineers, Ltd. Liquefied natural gas processing
US7191617B2 (en) 2003-02-25 2007-03-20 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US7216507B2 (en) 2004-07-01 2007-05-15 Ortloff Engineers, Ltd. Liquefied natural gas processing
US7219513B1 (en) 2004-11-01 2007-05-22 Hussein Mohamed Ismail Mostafa Ethane plus and HHH process for NGL recovery
US20080078205A1 (en) 2006-09-28 2008-04-03 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20080190136A1 (en) 2007-02-09 2008-08-14 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20080282731A1 (en) 2007-05-17 2008-11-20 Ortloff Engineers, Ltd. Liquefied Natural Gas Processing
US20090100862A1 (en) 2007-10-18 2009-04-23 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US7631516B2 (en) 2006-06-02 2009-12-15 Ortloff Engineers, Ltd. Liquefied natural gas processing
US20100236285A1 (en) 2009-02-17 2010-09-23 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100251764A1 (en) 2009-02-17 2010-10-07 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100275647A1 (en) 2009-02-17 2010-11-04 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100287982A1 (en) 2009-05-15 2010-11-18 Ortloff Engineers, Ltd. Liquefied Natural Gas and Hydrocarbon Gas Processing
US20100287984A1 (en) 2009-02-17 2010-11-18 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US20100287983A1 (en) 2009-02-17 2010-11-18 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing

Family Cites Families (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5634356A (en) * 1995-11-28 1997-06-03 Air Products And Chemicals, Inc. Process for introducing a multicomponent liquid feed stream at pressure P2 into a distillation column operating at lower pressure P1
UA76750C2 (uk) * 2001-06-08 2006-09-15 Елккорп Спосіб зрідження природного газу (варіанти)
US6742358B2 (en) * 2001-06-08 2004-06-01 Elkcorp Natural gas liquefaction
US6945075B2 (en) * 2002-10-23 2005-09-20 Elkcorp Natural gas liquefaction
EP1740897A4 (en) * 2004-04-26 2013-01-30 Ortloff Engineers Ltd LIQUEFACTION OF NATURAL GAS
US20110067441A1 (en) * 2009-09-21 2011-03-24 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing

Patent Citations (54)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US33408A (en) 1861-10-01 Improvement in machinery for washing wool
US2952984A (en) 1958-06-23 1960-09-20 Conch Int Methane Ltd Processing liquefied natural gas
US3292380A (en) 1964-04-28 1966-12-20 Coastal States Gas Producing C Method and equipment for treating hydrocarbon gases for pressure reduction and condensate recovery
US3837172A (en) 1972-06-19 1974-09-24 Synergistic Services Inc Processing liquefied natural gas to deliver methane-enriched gas at high pressure
US4061481A (en) 1974-10-22 1977-12-06 The Ortloff Corporation Natural gas processing
US4061481B1 (ar) 1974-10-22 1985-03-19
US4171964A (en) 1976-06-21 1979-10-23 The Ortloff Corporation Hydrocarbon gas processing
US4140504A (en) 1976-08-09 1979-02-20 The Ortloff Corporation Hydrocarbon gas processing
US4157904A (en) 1976-08-09 1979-06-12 The Ortloff Corporation Hydrocarbon gas processing
US4251249A (en) 1977-01-19 1981-02-17 The Randall Corporation Low temperature process for separating propane and heavier hydrocarbons from a natural gas stream
US4185978A (en) 1977-03-01 1980-01-29 Standard Oil Company (Indiana) Method for cryogenic separation of carbon dioxide from hydrocarbons
US4278457A (en) 1977-07-14 1981-07-14 Ortloff Corporation Hydrocarbon gas processing
US4519824A (en) 1983-11-07 1985-05-28 The Randall Corporation Hydrocarbon gas separation
US4690702A (en) 1984-09-28 1987-09-01 Compagnie Francaise D'etudes Et De Construction "Technip" Method and apparatus for cryogenic fractionation of a gaseous feed
US4617039A (en) 1984-11-19 1986-10-14 Pro-Quip Corporation Separating hydrocarbon gases
US4689063A (en) 1985-03-05 1987-08-25 Compagnie Francaise D'etudes Et De Construction "Technip" Process of fractionating gas feeds and apparatus for carrying out the said process
US4687499A (en) 1986-04-01 1987-08-18 Mcdermott International Inc. Process for separating hydrocarbon gas constituents
US4854955A (en) 1988-05-17 1989-08-08 Elcor Corporation Hydrocarbon gas processing
US4869740A (en) 1988-05-17 1989-09-26 Elcor Corporation Hydrocarbon gas processing
US4889545A (en) 1988-11-21 1989-12-26 Elcor Corporation Hydrocarbon gas processing
US5114451A (en) 1990-03-12 1992-05-19 Elcor Corporation Liquefied natural gas processing
US5275005A (en) 1992-12-01 1994-01-04 Elcor Corporation Gas processing
US5568737A (en) 1994-11-10 1996-10-29 Elcor Corporation Hydrocarbon gas processing
US5555748A (en) 1995-06-07 1996-09-17 Elcor Corporation Hydrocarbon gas processing
US5566554A (en) 1995-06-07 1996-10-22 Kti Fish, Inc. Hydrocarbon gas separation process
US5771712A (en) 1995-06-07 1998-06-30 Elcor Corporation Hydrocarbon gas processing
US5799507A (en) 1996-10-25 1998-09-01 Elcor Corporation Hydrocarbon gas processing
US5983664A (en) 1997-04-09 1999-11-16 Elcor Corporation Hydrocarbon gas processing
US5890378A (en) 1997-04-21 1999-04-06 Elcor Corporation Hydrocarbon gas processing
US5881569A (en) 1997-05-07 1999-03-16 Elcor Corporation Hydrocarbon gas processing
US6182469B1 (en) 1998-12-01 2001-02-06 Elcor Corporation Hydrocarbon gas processing
US6915662B2 (en) 2000-10-02 2005-07-12 Elkcorp. Hydrocarbon gas processing
US6578379B2 (en) 2000-12-13 2003-06-17 Technip-Coflexip Process and installation for separation of a gas mixture containing methane by distillation
US6712880B2 (en) 2001-03-01 2004-03-30 Abb Lummus Global, Inc. Cryogenic process utilizing high pressure absorber column
US7069743B2 (en) 2002-02-20 2006-07-04 Eric Prim System and method for recovery of C2+ hydrocarbons contained in liquefied natural gas
US6604380B1 (en) 2002-04-03 2003-08-12 Howe-Baker Engineers, Ltd. Liquid natural gas processing
US6941771B2 (en) 2002-04-03 2005-09-13 Howe-Baker Engineers, Ltd. Liquid natural gas processing
US7191617B2 (en) 2003-02-25 2007-03-20 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US6907752B2 (en) 2003-07-07 2005-06-21 Howe-Baker Engineers, Ltd. Cryogenic liquid natural gas recovery process
US7155931B2 (en) 2003-09-30 2007-01-02 Ortloff Engineers, Ltd. Liquefied natural gas processing
US7216507B2 (en) 2004-07-01 2007-05-15 Ortloff Engineers, Ltd. Liquefied natural gas processing
US7219513B1 (en) 2004-11-01 2007-05-22 Hussein Mohamed Ismail Mostafa Ethane plus and HHH process for NGL recovery
US20060283207A1 (en) 2005-06-20 2006-12-21 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US7631516B2 (en) 2006-06-02 2009-12-15 Ortloff Engineers, Ltd. Liquefied natural gas processing
US20080078205A1 (en) 2006-09-28 2008-04-03 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20080190136A1 (en) 2007-02-09 2008-08-14 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20080282731A1 (en) 2007-05-17 2008-11-20 Ortloff Engineers, Ltd. Liquefied Natural Gas Processing
US20090100862A1 (en) 2007-10-18 2009-04-23 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100236285A1 (en) 2009-02-17 2010-09-23 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100251764A1 (en) 2009-02-17 2010-10-07 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100275647A1 (en) 2009-02-17 2010-11-04 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100287984A1 (en) 2009-02-17 2010-11-18 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US20100287983A1 (en) 2009-02-17 2010-11-18 Ortloff Engineers, Ltd. Hydrocarbon Gas Processing
US20100287982A1 (en) 2009-05-15 2010-11-18 Ortloff Engineers, Ltd. Liquefied Natural Gas and Hydrocarbon Gas Processing

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
Mowrey, E. Ross., "Efficient, High Recovery of Liquids from Natural Gas Utilizing a High Pressure Absorber," Proceedings of the Eighty-First Annual Convention of the Gas Processors Association, Dallas, Texas, Mar. 11-13, 2002-10 pages.

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10533794B2 (en) 2016-08-26 2020-01-14 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US10551118B2 (en) 2016-08-26 2020-02-04 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US10551119B2 (en) 2016-08-26 2020-02-04 Ortloff Engineers, Ltd. Hydrocarbon gas processing
US11428465B2 (en) 2017-06-01 2022-08-30 Uop Llc Hydrocarbon gas processing
US11543180B2 (en) 2017-06-01 2023-01-03 Uop Llc Hydrocarbon gas processing
US11578915B2 (en) 2019-03-11 2023-02-14 Uop Llc Hydrocarbon gas processing
US11643604B2 (en) 2019-10-18 2023-05-09 Uop Llc Hydrocarbon gas processing

Also Published As

Publication number Publication date
BR112012006219A2 (pt) 2017-06-06
CN102575898B (zh) 2015-01-07
BR112012006277A2 (pt) 2017-05-23
EP2480845A1 (en) 2012-08-01
AU2010308519A1 (en) 2012-05-17
EA021947B1 (ru) 2015-10-30
EA201200520A1 (ru) 2012-09-28
EG27017A (en) 2015-04-01
EA024075B1 (ru) 2016-08-31
SA110310707B1 (ar) 2014-10-21
JP5850838B2 (ja) 2016-02-03
CN102498360B (zh) 2015-02-18
JP5793145B2 (ja) 2015-10-14
CO6531455A2 (es) 2012-09-28
EP2480847A4 (en) 2018-07-18
AR078401A1 (es) 2011-11-02
WO2011034709A1 (en) 2011-03-24
MY163645A (en) 2017-10-13
US20110067443A1 (en) 2011-03-24
CN102575898A (zh) 2012-07-11
TWI477595B (zh) 2015-03-21
ZA201202633B (en) 2012-12-27
NZ599335A (en) 2014-05-30
CA2773157A1 (en) 2011-04-28
MX348674B (es) 2017-06-23
PE20121420A1 (es) 2012-10-26
EG26970A (en) 2015-02-23
MX2012002970A (es) 2012-09-12
CO6531456A2 (es) 2012-09-28
CN102498359A (zh) 2012-06-13
BR112012006279A2 (pt) 2017-05-23
AU2010295870A1 (en) 2012-05-17
NZ599331A (en) 2014-05-30
MY161462A (en) 2017-04-14
KR20120069732A (ko) 2012-06-28
CA2772972A1 (en) 2011-03-24
NZ599333A (en) 2014-05-30
CA2773211A1 (en) 2011-03-24
CO6531461A2 (es) 2012-09-28
US20160377341A1 (en) 2016-12-29
AR078402A1 (es) 2011-11-02
KR101619568B1 (ko) 2016-05-10
KR20120072373A (ko) 2012-07-03
SG178603A1 (en) 2012-04-27
TW201127471A (en) 2011-08-16
JP2013505421A (ja) 2013-02-14
WO2011034710A1 (en) 2011-03-24
AU2010295869A1 (en) 2012-05-17
JP5793144B2 (ja) 2015-10-14
CA2773211C (en) 2018-10-30
CN102498359B (zh) 2014-09-17
KR20120069729A (ko) 2012-06-28
SA110310705B1 (ar) 2014-10-16
EA028835B1 (ru) 2018-01-31
EA201200521A1 (ru) 2012-09-28
MX2012002969A (es) 2012-08-08
TW201127945A (en) 2011-08-16
US20110067442A1 (en) 2011-03-24
CA2772972C (en) 2016-03-15
CL2012000706A1 (es) 2012-08-24
CN102498360A (zh) 2012-06-13
AU2010308519B2 (en) 2015-05-07
JP2013505239A (ja) 2013-02-14
WO2011049672A1 (en) 2011-04-28
EP2480847A1 (en) 2012-08-01
AU2010295869B2 (en) 2015-07-09
TW201111725A (en) 2011-04-01
CA2773157C (en) 2016-06-14
EA201200524A1 (ru) 2012-09-28
MX351303B (es) 2017-10-10
PE20121422A1 (es) 2012-10-26
PE20121421A1 (es) 2012-10-26
SG178933A1 (en) 2012-04-27
CL2012000687A1 (es) 2012-08-24
CL2012000700A1 (es) 2012-08-24
SA110310706B1 (ar) 2014-10-16
MX2012002971A (es) 2012-09-12
JP2013505422A (ja) 2013-02-14
MY163891A (en) 2017-11-15
US20110067441A1 (en) 2011-03-24
SG178989A1 (en) 2012-04-27
ZA201202696B (en) 2012-12-27
EP2480846A1 (en) 2012-08-01

Similar Documents

Publication Publication Date Title
US9476639B2 (en) Hydrocarbon gas processing featuring a compressed reflux stream formed by combining a portion of column residue gas with a distillation vapor stream withdrawn from the side of the column
US8919148B2 (en) Hydrocarbon gas processing
US8590340B2 (en) Hydrocarbon gas processing
US7191617B2 (en) Hydrocarbon gas processing
US9939195B2 (en) Hydrocarbon gas processing including a single equipment item processing assembly
US9933207B2 (en) Hydrocarbon gas processing
US9057558B2 (en) Hydrocarbon gas processing including a single equipment item processing assembly
US9068774B2 (en) Hydrocarbon gas processing
US20190170435A1 (en) Hydrocarbon Gas Processing
US20080078205A1 (en) Hydrocarbon Gas Processing
US11578915B2 (en) Hydrocarbon gas processing
US11643604B2 (en) Hydrocarbon gas processing
US20210116174A1 (en) Hydrocarbon gas processing

Legal Events

Date Code Title Description
AS Assignment

Owner name: ORTLOFF ENGINEERS, LTD., TEXAS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:MARTINEZ, TONY L.;WILKINSON, JOHN D.;LYNCH, JOE T.;AND OTHERS;SIGNING DATES FROM 20101018 TO 20101104;REEL/FRAME:025352/0223

STCF Information on status: patent grant

Free format text: PATENTED CASE

CC Certificate of correction
MAFP Maintenance fee payment

Free format text: PAYMENT OF MAINTENANCE FEE, 4TH YEAR, LARGE ENTITY (ORIGINAL EVENT CODE: M1551); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY

Year of fee payment: 4

AS Assignment

Owner name: UOP LLC, ILLINOIS

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:ORTLOFF ENGINEERS, LTD.;REEL/FRAME:054188/0807

Effective date: 20200918

MAFP Maintenance fee payment

Free format text: PAYMENT OF MAINTENANCE FEE, 8TH YEAR, LARGE ENTITY (ORIGINAL EVENT CODE: M1552); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY

Year of fee payment: 8